Conduit liner for wellbore and method and apparatus for setting same

ABSTRACT

A method of emplacing a liner in a conduit in a well penetrating subterranean formations characterized by positioning with a wire line a cylindrical annular liner at a given depth in the well, the liner being disposed adjacent a swaging mandrel and a setting sleeve, both being connected with a setting tool; actuating the charge in the setting tool to force the swaging mandrel through the liner and to oppose movement of the liner by a reactive force on the setting sleeve, thereby expanding the liner outwardly into tight frictional engagement with the conduit without requiring an anchor or supplemental support; and removing the other apparatus from the well. Also disclosed are specific arrangements and combinations of respective embodiments and some of the uses of the liner.

finite States aternt Owen et a1.

CONDUIT LINER FOR WELLBORE AND METHOD AND APPARATUS FOR SETTING SAMEInventors: Harrold D. Owen; Wayne 0.

Rosenthal; james Douglas Young afi' oi'T ort Worth, Tex.

Gearhart-Owen Industries, Inc.,

Forth Worth, Tex.

Filed: July 26, 1971 Appl. No.: 166,066

Assignee:

Related U.S. Application Data Continuation-impart of Ser. No. 878,108,Nov. 19, 1969, abandoned.

U.S. Cl. ..166/277, 166/63, 166/315, 166/297 Int. Cl. ..E2lb 23/04, E21b43/10 Field of Search ..166/277, 315, 63, 206, 207, 166/297; 29/522, 523

References Cited UNITED STATES PATENTS Howard et a1. ..l66/63 Vincent..166/277 3,186,485 6/1965 Owen ..l66/63 3,191,680 6/1965 Vincent.......166/207 X 3,245,471 4/1966 Howard... ..166/315 3,220,480 11/1965Myers ..166/63 3,498,376 3/1970 Sizer et a1. ....l66/207 X 3,412,56511/1968 Lindsey et al. ..29/523 X Primary Examiner-David H. BrownAtt0rneyWm. T. Wofford et a1.

[57] ABSTRACT A method of emplacing a liner in a conduit in a wellpenetrating subterranean formations characterized by positioning with awire line a cylindrical annular liner at a given depth in the well, theliner being disposed adjacent a swaging mandrel and a setting sleeve,both being connected with a setting tool; actuating the charge in thesetting tool to force the swaging mandrel through the liner and tooppose movement of the liner by a reactive force on the setting sleeve,thereby expanding the liner outwardly into tight frictional engagementwith the conduit without requiring an anchor or supplemental support;and removing the other apparatus from the well. Also disclosed arespecific arrangements and combinations of respective embodiments andsome of the uses of the liner.

39 Claims, 21 Drawing Figures PATENTEDJAH 23 I975 SHEET 1 [IF 7 Fi lPATENTEDJAHZB I875 SHEET 3 BF 7 Fly. 7

PATENTEUJAN 23 ms SHEET 5 BF 7 ATTORNEYS CONDUIT LINER FOR WELLBORE ANDMETHOD AND APPARATUS FOR SETTING SAME CROSS REFERENCE TO RELATEDAPPLICATIONS This application is a continuation-in-part of applicationSer. No. 878,l08, filed Nov. 19, 1969, now abandoned.

BACKGROUND OF THE INVENTION 1. Field of the Invention This inventionrelates to methods and apparatus for use in a well penetratingsubterranean formations. More particularly, it relates to methods,liners and combinations of apparatus employing a liner in casing ortubing in an oil well or the like.

2. Description of the Prior Art The prior art is replete with practicaland impractical liners, and methods and apparatus for setting the linersin the casing or tubing in a well. As is well known, the liners areordinarily set by being expanded outwardly into tight frictionalengagement with the conduit; such as, the casing or the tubing. Thedegree and type of tight frictional engagement depends, of course, onthe use, or application, for which the liners are intended. For mostapplications, the liners are set with a tightness that prevents unwantedmovement longitudinally of the conduit. Frequently, the liners are setwith both tight frictional and sealing engagement, as will be apparentfrom a description of specific embodiments hereinafter. The tightfrictional engagement provides a finite force that is designed forretaining the liner in place to do its job. Obviously, forces largerthan design can be generated that are large enough to move the set linerlongitudinally of its conduit. Liners or plugs have been set in a wellby detonation of explosives within an enclosed chamber, or about amandrel within a conduit; bridge plugs have been set by drawing amandrel up within an expansible annular body and leaving the mandrelemplaced within the annular body, and by driving an expanding bodyupwardly or downwardly into and through an expansible body retained inposition by a supplemental anchor or support means; such as, a tubingstop or a string of conduit supported on a bottom of the well. Linershave been set by hydraulically forcing a swaging mandrel, or swagemeans, upwardly through corrugated liners held in place by the tubingstring. Liners have also been set by jarring by repeated firing of anexplosive jar brought to the surface and reloaded between firings and byexplosively driving a swage means upwardly or downwardly through acorrugated liner held in place by a frangible member with a secondexplosive charge within the frangible member to destroy it. While someof the prior art devices have been useful, they have suffered from oneor more of the following disadvantages:

1. they depended upon a separate supplemental support which had toengage the conduit and had to be individually set in the well forsatisfactory operation, the supplemental supports were often unreliableand even if successful effected a surface discontinuity that createdcorrosion problems later;

2. they depended upon an outside coating of resilient material foreffecting the sealing;

3. they required two parts; such as, an inner mandrel for setting andretaining in place;

4. they were limited to thin walls because of the relatively largeflexure of certain corrugations in the walls;

5. they had regions of relatively low yield strength because of thelarge amount offlexure induced by corrugations;

6. the resulting structure emplaced in the well-bore had a restrictedaperture that was not as smooth as desired therethrough;

7. if they formed seats with a smooth internal diameter they werelimited to seating at joints;

8. they required a separate string of pipe for operation; for example,either for rotating or jarring a tool or for conveying a high pressurefluid thereto;

9. they required a plurality of trips into the well to effect passage ofthe swage means completely through the liner;

10. they destroyed a portion of the equipment and sometimes damagedother equipment in the well by an uncontained explosion; or

ll. they employed in the liner materials that were objectionable becauseof their physical, chemical, or electrochemical properties; for example,they formed galvanic, or electrolytic, cells with the conduit, therebycausing localized corrosion.

It is a primary object of this invention to provide an improved methodof and combinations of apparatus for setting a liner in a conduit in awellbore penetrating subterranen formations that alleviate thedisadvantages of the prior art devices and methods, as enumeratedhereinbefore.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a schematic elevational viewof the liner and apparatus for setting it in a casing in a wellpenetrating subterranean formations, in accordance with one embodimentof the invention.

FIGS. 2 and 3 are fragmentary longitudinal sectional views of,respectively, the upper and lower parts of the device of FIG. 1, showingthe device in one operative position.

FIGS. 4 and 5 are fragmentary longitudinal sectional views of,respectively, the upper and lower parts of the device of FIG. 1, showingthe device in another operative position.

FIGS. 6 and 7 are fragmentary longitudinal sectional views illustratinganother embodiment of the invention employed in hanging a productionliner within a casing in a well.

FIGS. 8 and 9 are fragmentary longitudinal sectional views of anotherembodiment of the invention employed in emplacing a bull plug seal meansin a casing in a well.

FIGS. 10, l1 and 12 are fragmentary longitudinal sectional viewsillustrating another embodiment of the invention employed in emplacing astraddle patch in a casing in a well.

FIG. 13 is a fragmentary longitudinal sectional view of anotherembodiment of this invention employed in emplacing a seal sub in acasing in a well.

FIG. 14 is an elevational cross sectional view of a seal nipple foremplacing in the seal sub of FIG. 13.

FIG. 15 is a cross sectional view of a multiple bore packer emplaced inthe embodiment of FIG. 13.

FIG. 16 is a fragmentary longitudinal sectional view taken along theline XVI XVI of FIG. 15.

FIG. 17 is a fragmentary longitudinal sectional view illustratinganother embodiment of this invention wherein the liner is disposed aboveboth the swage means and the setting sleeve means.

FIG. 18 is a fragmentary longitudinal sectional view of the embodimentof FIG. 17 containing a seal unit and emplaced in the conduit in thewell.

FIG. 19 is a fragmentary longitudinal sectional view illustratinganother embodiment of this invention wherein the liner is disposed belowboth the swage means and the setting sleeve means.

FIG. 20 is a fragmentary longitudinal sectional view of the embodimentof FIG. 19 after the liner has been expanded into tight frictionalengagement with the conduit in the well.

FIG. 21 is a fragmentary longitudinal sectional view illustratinganother construction of the swage means of the embodiment of FIG. 19.

DESCRIPTION OF PREFERRED EMBODIMENTS Referring now to the drawings, FIG.1 illustrates a setting tool device 11, having liner 13 disposed betweenswage means and setting sleeve means 17, all suspended from a wire line19 at a given depth in a section of casing 21 in wellbore 23 penetratingsubterranean formations 25. A collar locator and cable head assembly 27is ordinarily included to facilitate accurate emplacement of the linerand withdrawal of the setting tool device.

The setting tool device which is illustrated in cross section in FIGS. 2and 3 is described in detail in U. S.

Pat. No. 3,186,485, Setting Tool Devices, Harrold D. Owen. Reference ismade to that patent for a detailed description of the operation of thesetting tool. Broadly, the setting tool is a type of force generatingmeans wherein a piston assembly and a cylinder assembly are powered formovement relative to each other by an ignitable charge in the tool.Briefly, setting tool device 11 includes fluid actuated means comprising a head assembly including igniter means, a cylinder assembly and apiston assembly within the cylinder assembly, with the piston assemblybeing slideable relative to the cylinder assembly; and means including acombustion chamber adapted for receiving a combustible material powercharge and disposed within the cylinder assembly for imparting motion tothe cylinder assembly relative to the piston assembly to move the swagemeans upwardly through the liner, movement of which is opposed by thesetting sleeve means. For ease of explanation the setting tool isillustrated herein as having its piston assembly connected with theswage means and its cylinder assembly connected with the setting sleevemeans. Adapter means are available to effect the converse connection inwhich the cylinder assembly is connected with the swage means and thepiston assembly is connected with the setting sleeve means if desired.

Referring to FIGS. 2 and 3, liner 13 is accurately positioned at a givendepth; for example, by use of collar locator 27. The given depth mayinclude a section of casing 21 having a leak such as formed by anaperture 28 therein. Liner 13 includes an annular body portion havinginterior and exterior surfaces that define cylinders that are at leastpartially coextensive. The body portion has an outside diameter lessthan the diameter of the casing, or conduit; has sufficient malleabilityfor and is adapted for being expanded to conformingly engage the casing;and has a wall thickness sufficient to effect a wall after expansioncapable of withstanding differential pressure between the inside andoutside of the casing. The body portion of the liner has a modulus ofelasticity in compression sufficient to retain tight frictionalengagement with the conduit after being expanded thereagainst andprevent being displaced upwardly or downwardly by forces normallyexpected to be imposed on the liner. The liner 13 is disposed adjacent aswage means 15 for being expanded outwardly into tight frictionalengagement with the conduit such as the casing in the well; and isdisposed adjacent a setting sleeve means 17 for holding the liner at thedesired setting depth against the force of the swage means 15 as theswage means 15 is forced through the liner. As illustrated, the liner 13is disposed between swage means 15 and setting sleeve means 17.Expressed otherwise, swage means 15 is disposed below liner 13 formoving through and expanding the liner outwardly and into contact withthe casing, the external dimensions of the swage means having beenpreselected in accordance with the internal dimensions of the casing andthe diameters and wall thickness of the liner to effect the necessaryfrictional engagement and the necessary thickness of the wall afterexpansion into engagement with the casing.

An adapter rod means such as adapter rod 29, FIG. 3, is provided forconnecting the swage means 15 with a force generating means such as thesetting tool device 11. As illustrated in FIG. 3, adapter rod 29 passesthrough the liner 13, is connected at one end portion with swage means15 and is adapted for connection at the other end with a forcegenerating means for subjecting the swage means to a force actingupwardly for pulling the swage means upwardly through the liner.

Setting sleeve means 17 is disposed radially of the central axis of theadapter rod 29. As illustrated, the setting sleeve means 17 encirclesthe adapter rod 29 and has its lower end portion engaging the top of theliner and being adapted at its upper end portion for connection with theforce generating means for opposing upward movement of the liner bytransmission of a downwardly acting reactive force from the forcegenerating means.

When setting tool device 11 is employed as the force generating means,adapter rod 29 is connected at its upper end with bottom piston 31 ofthe piston assembly of setting tool device 11. Setting tool device 11also includes a top piston 33, a top piston connecting rod 35, a toppiston extension rod 37, and a firing head 39 surmounted by a quickchange assembly 41. Setting sleeve means 17 is connected with bottomcylinder 43 of the cylinder assembly of setting tool device 11. Thecylinder assembly also includes top cylinder 45 and top sub 47.

A shear plug 49, having a predetermined shear value, is threadedlyinserted into matched holes in the upper cylindrical portion 51 andlower body portion 53. Upon ignition of the ignitible charge in thesetting tool, shear plug 49 is sheared and a force generated to pullswage means 15 through liner 13. Movement of liner 13 is op-. posed bythe downwardly acting reactive force via the cylinder assembly andsetting sleeve means 17 and another operative position, illustrated inFIGS. 4 and 5, is assumed as the swage means is pulled through liner 13to expand it out into frictional and sealing engagement with casing 21.

Specifically, setting sleeve means 17 expandibly engages the top of theliner via expander means; such as, flexible spring fingers 55. Theflexible spring fingers 55 are ordinarily of steel. The flexible springfingers 55 retain the liner in place during setting but are adapted toflex outwardly to allow passage of the swage means therethrough, asillustrated in FIG. 5 and spring back into position after the swagemeans has passed therethrough.

To allow the flexible spring fingers to transmit the reactive force andoppose the force pulling swage means 15 through liner 13, an expandersupport ring 57 is employed in the setting sleeve means 17 and is heldin place adjacent liner l3 and within the flexible spring fingers with ashearable means; such as, shear pins 59; for supporting the fingersduring the interaction of the large force and reactive force pulling theswage means through the liner. Expander support ring 57 has an annularshoulder 61 for conformingly engaging a shoulder portion 63 of the swagemeans after the swage means has passed through the liner for moving theexpander support ring upwardly as the swage means passes upwardly out ofthe liner.

The swage means is connected with the adapter rod by a tension releaseportion 65 having a weak point to facilitate removal of the setting tooldevice in the event malfunction occurs to prevent removal of the linerand the swage means.

Swage means 15 is illustrated as a ball swage in which the exteriorsurfaces form a circle such that upon being pulled through liner 13 aninterior cylindrical surface is generated. Any other swage means capableof generating a smooth, cylindrical interior surface and having therequisite strength to expand liner 13 out against the conduit with theforce available in the force generating means can be employed.

Swage means 15 contains a central passageway 83 and branch passageways85 and 86 to facilitate flow of fluids therethrough. In this way theliner and the setting apparatus can be run rapidly down casing 21 toreach the proper depth more quickly. Swage means 15 contains threadedapertures 87 at each end for receiving a tension release portion 65 andallow interconnecting it with adapter rod 29, as well as other adapterrods. Threaded aperture 87 is merely illustrative of a satisfactoryinterconnection means. Any other interconnection means can be employedif desired.

As can be seen in FIGS. 4 and 5, when the combustible charge is nearlyspent, the piston assembly including bottom piston 31, top piston 33,top piston connecting rod 35, and top piston extension rod 37; firinghead 39, and quick change assembly 41 will have moved upwardly withrespect to the cylinder assembly including bottom cylinder 43, topcylinder 45 and top sub 47. As swage means 15 moves out of the topportion of liner 13, its shoulder portion 63 engages annular shoulder 61of expander support ring 57, shearing shear pins 59 and moving expandersupport ring 57 upwardly. Spring fingers 55 move outwardly to allowswage means 15 to pass therethrough, retaining engagement with the topedge ofliner l3 The liner is placed in the well by the followingprocedure. The liner and its setting apparatus, setting tool and anyaccessory equipment are inserted through conventional wellhead andlubricator equipment; and lowered to the desired depth on wire line 19.As indicated hereinbefore, once the liner is accurately positioned atthe desired depth in the conduit in the well the force generating meanscomprising an ignitable charge in the setting tool is actuated, thereby,normally in a single stroke, pulling the swage means upwardly throughthe liner and expanding the liner outwardly into physical contact withthe conduit with sufficient force to retain it in place. In detailedoperation, as relative longitudinal movement starts to occur between theliner 13 and the swage means 15 in response to the upwardly anddownwardly acting forces from the force generating means, the liner isforced outwardly to engage the casing 21. The engagement of the liner 13with the casing 21 stops downward movement of the liner, obviating theneed for an anchor of any sort. Thereafter, for all practical purposes,the force of the setting tool is directed to pulling the swage means 15upwardly through the liner 13 which has been immobilized in tightfrictional engagement with the casing 21. Following the settingoperation, the setting tool, the swage means and the setting sleevemeans and accessories are removed from the well, leaving the liner inplace having an unusually large aperture penetrating longitudinallytherethrough.

The liner remaining emplaced in the casing has uniform crystallographicstructure since it has been substantially uniformly expanded outwardlyto engage the casing, or other conduit, into which it is emplaced. Theliner has a smooth bore which will serve as a seat against which to sealother elements.

The liner may be formed of any material having the requisitemalleability and modulus of elasticity in compression after expansionagainst the conduit. Ordinarily, the liner will be a metallic liner. Forexample, alloys of copper, magnesium, aluminum or iron may be employed.The soft steels form satisfactory liners, since they have the requisiteproperties and do not set up any galvanic cells, regardless of the fluidin the conduit or outside the conduit in the well. A surprising andparticularly preferred material of construction is commercially pureiron such as is employed in magnetic ingots for making iron cores ofelectromagnets, relays, and the like. The commercially pure iron is ahighly refined open hearth grade of low-carbon, low-manganese iron. Ithas less than one percent by weight of alloy constituents, or otherelements, and is described in detail in our co-pending application Ser.No. 166,032 entitled Conduit Liner for Wellbore, filed July 26, 1971.

When softer metals; such as, aluminum, magnesium, or alloys of copper;are employed as the body portion of the liner, it is preferable toinclude a top portion integrallyconnected with the body portion. The topportion should have a plurality of notches in its top edge to affordniches into which the metal can extrude when the swage means is pulledupwardly through the body portion of the liner. in this way, the metaldoes not extrude between the spring fingers of the setting sleeve.

When the liner is to be employed as other than a patch for the conduit,it is preferable to include integrally connected with the body portionof the liner a top portion that has an inner inverted frusto-conicalsection to form a stabbing section to facilitate entry of other elementsinto the liner once emplaced in the well.

If desired, a coating of a supplementary material may be employed on theexterior surface of the liner to facilitate effecting a seal with theconduit into which the liner is emplaced. When such an external coatingis employed, care should be taken that the material of which the coatingis made does not extrude from between the liner and the conduit underthe differential pressures that may exist thereacross and that thematerial is not soluble in fluid in contact with it so as to bedissolved from between the liner and the conduit.

In other embodiments, the liner can be employed with a connector meansfor connecting with a terminal element. The connector means is connectedat one of its ends with the body portion of the liner and at the otherof its ends with the terminal element. The terminal element may compriseconventional or newly developed downhole equipment; and, typically,includes equipment such as a production liner; a bull plug seal means; aseal sub for a seal nipple or packer; or an intermediate conduit of astraddle patch. Preferably for most downhole applications, the connectormeans is sealingly connected with the liner and with the terminalelement; and has an expansible portion for retaining the sealinginterconnection after the body portion of the liner has been expandedoutwardly into tight frictional engagement with the conduit in the well.The connector means may be connected with either the top or the bottomof the respective liner, as most expeditious in connecting with theterminal element. The connector means may be connected with the terminalelement by conventional means; such as, a threaded connection; or by anexpansible portion, depending upon the nature of the terminal element.The connector means may be integral with or carried by either theterminal element or the liner, or it may be detachably connected witheither or both, as by threaded connection. A variety of typicalconnector means are illustrated in the figures hereinafter referred toand the accompanying descriptive matter.

Referring to FIG. 6, liner 13 is connected at its lower extremity withconnector means 67. The expansible connector portion of the connectormeans 67 is illustrated as being integrally formed with liner 13. Ifdesired, and as implied hereinbefore, it may be affixed by any suitableexpansible joint; for example, it may be thermally joined thereto; as bywelding, or silver soldering. At its other end, or lower end portion 69,connector means 67 may be threaded to facilitate joining with sub 71onto which at least a section 73 of a production liner is affixed. Whilethreaded connections between connector means 67, sub 71 and productionliner 73 are illustrated, any suitable means can be employed for suchinterconnection.

The liner 13 of FIG. 6 is arranged and emplaced similarly as describedhereinbefore. Specifically, the liner 13 is disposed between swage means15 and setting sleeve means 17 for accurate placement within the conduitwhen swage means 15 is pulled through liner 13. The adapter rod 29 isconnected with a force generating means for pulling swage means 15through liner l3 and setting sleeve means 17 is connected with the forcegenerating means for imparting an opposing,

or reactive, force to retain the liner accurately positioned and opposeits being displaced upwardly by the movement of swage means 15therethrough. The force generating means is actuated to pull swage means15 through liner 13 and expand it out into frictional and sealingengagement with conduit which may be the same as casing 21. The forcegenerating means pulls swage means 15 through liner 13, effectingsimple, rapid, long lasting emplacement of the liner. Thereafter, theforce generating means, swage means 15, and setting sleeve means 17, aswell as the intermediate connections, are removed from the well.

FIG. 7 illustrates the liner 13 expanded into place against conduit 75,the connector means 67 with its upper expansible portion expanded withliner 13, the sub 71, and the production liner 73 emplaced in a conduit75 in the well-bore. The production liner may be employed as a sandscreen, or in connection with a gravel pack. Such production liners arefrequently employed in wells operating under secondary recoverytechniques; such as, flooding or thermal recovery. While the liners areordinarily of steel, in certain instances, such as thermal recovery,they may be of stainless steel, titanium or other oxidation resistantmetals or metallic alloys. The tough metals such as titanium requiregreater forces in setting, however, when they are employed in liner 13.Production liners are well known in the technology of producing oil fromsubterranean formations and need not be described in great detailherein.

When emplaced with liner 13, the production liner does not movedownwardly from its own weight. Neither is it moved upwardly by anypressure differential. Ordinarily, there is relatively smalldifferential pressure between the inside and the outside of a productionliner.

FIG. 8 illustrates liner 13 and connector means 67 employed to support abull plug seal means 79 within conduit 75 inside a wellbore. In thisembodiment of the invention, the liner is run downwardly through conduit75 relatively slowly to allow fluids within the conduit to flow past thebull plug seal means 79 and liner 13. Threaded connections areillustrated as the means by which bull plug seal means 79 is connectedwith the connector means 67. Any other suitable means may be employed tointerconnect the two.

After the desired depth has been achieved in the wellbore, operation ofthe setting apparatus is effected by actuation of the force generatingmeans as described hereinbefore. Upon actuation of the force generatingmeans, swage means 15 is pulled upwardly through liner 13, expanding theliner outwardly and into frictional and sealing engagement with conduit75. Setting sleeve means 17 is also connected with the force generatingmeans for opposing the relatively upward movement of swage means 15 withdownwardly acting reactive force to retain liner 13 at the desired depthin conduit 75 for emplacement.

FIG. 9 illustrates the liner l3 emplaced in conduit 75, the upper, orexpansible, portion 81 of connector means 67 being expanded outwardly toaccommodate the increased diameter of liner l3, and the lower portionretaining the original diameter and threadedly and sealingly connectedwith bull plug seal means 79.

In FIG. 9 spring fingers 55 are seen clearly after swage means 15 haspassed upwardly therethrough, moving expander support ring 57 upwardlyfrom within fingers 55. Setting sleeve means 17, swage means 15, as wellas the remainder of the force generating means are removed from conduit75 to leave bull plug seal means 79 firmly emplaced via liner 13 inconduit 75. Liner 13 sealingly and frictionally engages conduit 75 withsufficient force to prevent movement of bull plug seal means 79 upwardlyor downwardly by the force of any differential pressure across itnormally expected to be encountered. Such differential pressure may beappreciable since the purpose of the bull plug seal means is forisolating a zone of a particular fluid pressure from the remainder ofconduit 75. For example, the differential pressure may run as high as1000 to 3000 pounds per square inch, or higher. It is apparent,therefore, that the frictional engagement of liner 13 with conduit 75must resist displacement with a large frictional force. In someinstances where a large differential pressure is expected, the forcegenerating means may generate a force sufficient to expand the lineroutwardly to the extent that conduit 75 is also distorted slightly toincrease the force resisting movement upwardly or downwardly.

FIG. 10 illustrates another embodiment of the invention in which theconnector means 67 is sealingly connected with liner 13, includes anelongate sleeve portion 93, and is sealingly connected at its other endwith the annular body portion of a second liner 99 to form a straddlepatch for emplacing in the conduit for blocking a communicatingpassageway between the interior of the conduit 75 and the exterior ofthe conduit 75.

Specifically, liner 13 is threadedly connected with the connector means67 via an expansible portion comprising conforming threaded section 89and 91, and sealing means; such as, O-rings 95', that are employed toensure that liner 13 is sealingly connected with connector means 67after expansion.

Similarly, the lower end portion 97 incorporates threaded sections 89and 91 with O-rings 95 to form a second expansible portion 97 thatsealingly connects the connector means 67 with the second liner 99. Asillustrated, the connector means 67, incorporating its elongate sleeveportion 93 and two expansible portions, is connected with the bottom ofthe top liner 13 and the top of the bottom liner 99 to form the straddlepatch.

Swage means 15 is connected with a second swage means 101 below secondliner 99. Second swage means 101 has a diameter slightly less than thediameter of swage means 15 so that it will freely pass through theaperture left in liner 13 by the passage of swage means 15 therethrough.Moreover, the diameter of the second swage means 101 and the diametersand wall thickness of second liner 99 are selected so that theycooperate to effect sealing engagement of second liner 99 with conduit75 when second swage means 101 is drawn upwardly through second liner 99expanding it outwardly into sealing and frictional engagement withconduit 75.

It is important that the swage means pass through the associated linersto expand them outwardly into engagement with conduit 75 singly ratherthan simultaneously. In this way, setting sleeve means 17 is notrequired to supply the large force that would be required bysimultaneous passage of both swaging means through both liners. It isnot critical which swage means is pulled through its associated linerfirst.

As illustrated, second swage means 101 is immediately below andcontiguous with second liner 99 and swage means 15 is spaced a distancebelow liner l3 sufficient to enable second swage means 101 to transversethrough second liner 99 before swage means 15 starts its traverse ofliner 13.

Swage means 15 is connected via adapter rod 29 with the force generatingmeans and setting sleeve means 17 is connected with the force generatingmeans asdescribed hereinbefore.

Swage means 15 is connected with second swage means 101 by a secondadapter rod 107 and a second tension release means 109. Second tensionrelease means 109 enables removal of the portion of the apparatusthereabove in the event there is a malfunction which prevents removal ofthe second swage means from the conduit within the well.

The straddle patch formed by the two liners and the intermediate secondconduit will straddle passageways 103 communicating with an undesiredstrata by emplacing the straddle patch at the appropriate depth inconduit 75.

The force generating means is actuated to pull second swage means 101through second liner 99 and swage means 15 through liner 13.

An intermediate position in which second swage means 101 has passedthrough second liner 99 and in which swage means 15 is in the process ofbeing passed upwardly through liner 13, is illustrated in FIG. 11.Therein, second liner 99 has been expanded outwardly to sealingly andfrictionally engage conduit 75. Lower expansible end portion 97 ofconnector means 67 has been expanded with the body portion of secondliner 99. The conforming threaded sections 89 and 91 are expandedoutwardly to retain sealing engagement. 0- rings 95 also retain sealingengagement and ensure there is no leakage.

It may be advantageous to employ a connector means wherein the elongatesleeve portion 93 is threadedly and sealingly connected at each endportion to the respective expansible portions, in the manner as sub 71was engaged in FIG. 6. In this way, the threaded sealed portions of theconnector means are not expanded, thus lessening the chances ofa leak.

As swage means 15 is pulled upwardly through liner 13, spring fingers 55engage the top portion of the liner and resist its being displacedupwardly. Moreover, as swage means 15 passes through the lower portionof the liner 13 and the upper portion of connector means 67, they areexpanded outwardly to frictionally and sealingly engage a portion ofconduit 75, and help to retain the liner in place. Expander support ringenables spring fingers 55 to withstand the large force engendered by theinteraction between the upward acting force on adapter rod 29 and thedownward acting reactive force on setting sleeve means 17 without bowingor otherwise distoring.

FIG. 12 illustrates the straddle patch emplaced within conduit 75.Therein, liner 13 and second liner 99 are sealingly and frictionallyemplaced in conduit 75 and co-act with connector means 67 to effect astraddle patch which isolates passageway 103 from the interior ofconduit 75. Liner 13 has a stabbing section 111 comprising an invertedfrusto-conical section. As illustrated, top portion 111 has notches 113to allow room for extrusion of metal thereinto during the passage of theswage means through liner 13. Notches 1 13 are not ordinarily necessaryin second liner 99 since there are no adjacent spring fingers 55 intowhich metal will extrude. Moreover, extrusion of metal in second liner99 by passage of second swage means 101 therethrough, is of lesssignificance than at the top of liner 13.

A variety of other applications, or uses, of the liner 13 will beapparent once this invention becomes known. Illustrative of such otheruses is the use of a seal sub as the terminal element, the seal subbeing used to sealingly receive a large bore packer, or the like. Theterm large bore packer" is used in its broad sense to include singlebore packers and similar devices such as seal nipples, as well aspackers having a plurality of bores. The liner 13 connected viaconnector means 67 having an expansible portion 131 with a seal sub 133is illustrated emplaced in casing 21 in FIG. 13. The connector means isconnected with the body portion of the liner 13 via threaded connection135 and suitable sealing means 137; such as, an O-ring in an annularrecess. On the other hand, the connector means 67 is integrally formedwith the seal sub 133. As illustrated, the liner 13 contains suitableseal means 139 for ensuring a fluid impermeable interconnection betweenit and the casing 21. For example, the seal means 139 may comprise aplurality of O-ring type seals disposed in grooves 141 extendingperipherally around the liner 13. The seal sub 133 has a seal surface145 defining an internal bore and extending longitudinally thereof. Theseal surface 145 is provided with a smooth finish for sealing engagementwith the seal nipple, packer, or the like, that it is to sealinglyreceive.

A seal nipple 147 suitable for emplacing within the seal sub 133 isillustrated in FIG. 14. The seal nipple 147 is provided with a top andbottom connection means such as female threads 149 for sealinglyreceiving male threads on a compatible element; such as, a joint of pipein a string of conduit. In this way, the joint of pipe, or conduit, maybe screwed into the seal nipple 147 and lowered until the seal nipple147 is emplaced within the seal sub 133. If desired, suitable seal means151 such as O-ring type seals may be emplaced in grooves 153 extendingperipherally around the seal nipple 147. An undercut portion 155 isprovided for being gripped with a wrench or the like in order to holdthe seal nipple 147 while screwing the respective joints of pipe intothe threads 149, or for other purposes.

A packer 159 emplaced in the seal sub 133 is illustrated in FIGS. 15 and16. Whereas the seal nipple 147, FIG. 14, had a single aperture 161, thepacker 159 has a plurality of apertures 163-165 for receiving respectivestrings of conduit such as tubing and spaghetti strings. Suchsupplemental strings of conduit may be necessary in the production of aplurality of zones or in operating supplemental downhole equipment suchas gas lift valves or gas operated devices in which the gas is injectedthrough the spaghetti strings. n the other hand, the spaghetti stringsmay be employed for injection of chemicals; such as, corrosioninhibitors; paraffin deposition suppression chemicals; or the like. Inany event, the packer has a sealing surface 167 for being disposedadjacent the seal surface of the seal sub 133. If desired, suitable sealmeans 151 may be provided also in the body of the packer 159. The sealmeans 151 may be disposed in suitable grooves 153 extending peripherallyaround the body of the packer 159, similarly as described with respectto the seal nipple 147.

In operation, the liner 13 is set in the casing 21 as describedhereinbefore. Specifically, the liner is emplaced at the desired depthand the setting tool activated to pull the swage means upwardly throughthe liner to expand it out into tight frictional engagement with thecasing 21. The expansible portion of the connector means 67 expandsoutwardly to retain sealing engagement with the liner 13 as it isexpanded. Consequently, the seal sub 133 is sealingly connected with theliner 13. When the respective elements such as the seal nipple 147 orthe packer 159 is thereafter emplaced sealingly within the seal surface145 of the seal sub 133, there is a fluid impermeable block formed;although fluid may flow through the bores of the respective apertureswithin the element so emplaced. The bores 163-165 may have conduitssealingly emplaced within them so that the conduits define the flowpassageways, whereas the single aperture 161 of the seal nipple 147 maydefine the flow passageway therethrough.

While the straddle patch illustrated in FIGS. 10-12 employed a unitaryelongate sleeve portion 93, the sleeve portion may comprise a pluralityof joined sections, if desired.

In the embodiments illustrated and described hereinbefore, the liner hasbeen shown above the swage means and below the setting sleeve means tofacilitate expansion of liner outwardly into the conduit by drawing theswage means upwardly therethrough. If desired, the liner may be disposedeither above both the swage means and the setting sleeve means or belowboth the swage means and setting sleeve means.

For example, FIGS. 17 and 18 illustrate an embodiment in which the liner13 is disposed above both swage means 171 and setting sleeve means 173.In FIG. 17 the combination comprises, in addition to the swage means 171and the setting sleeve means 173, adapter rod means 175 and thrust means177 for effecting the desired interconnection between the respectiveelements of a force generating means such as setting tool device 11 andthe swage means 171 and setting sleeve means 173.

The swage means 171 has its external dimensions sized, as describedhereinbefore with respect to swage means 15, to effect expansion of theliner 13 into tight frictional engagement with the conduit, such as thecasing 21, in the wellbore. The swage means 171 has a spherical exteriorsurface 179 for effecting a smooth internal bore in the liner after ithas been expanded. The swage means 171 has a cylindrical interior 181and is movable longitudinally with respect to thrust member 183 of thethrust means 177. The swage means 171 is structurally strong so as toexpand the liner 13 outwardly into tight frictional engagement with thecasing 21 without being compressed inwardly enough to bind on thrustmember 183 as the swage means 171 passes upwardly through the liner 13.

The adapter rod means 175 is connected at one end portion with the swagemeans 171 and has, at its other end portion, means 185 for connectionwith a portion ofa force generating means; such as, the bottom piston 31of the piston assembly of the setting tool device 11; for pulling theswage means 171 upwardly through the liner 13. The adapter rod means175, as illustrated, comprises a generally cylindrical member that isdisposed exteriorly radially of the thrust member 183 and has slots 201for accommodating movement of a crossover pin longitudinally thereof.The adapter rod means 175 extends downwardly through liner 13.

The setting sleeve means 173 has its upper end portion connected withthe liner 13, as by threaded connection 187. Setting sleeve means 173has a first shoulder portion 189 that removably abuts a second shoulderportion 191 of the thrust member 183. Thus, the setting sleeve means 173is adapted for transmitting a tensile force to hold downwardly on theliner 13 to prevent its movement upwardly as the swage means 171 isdrawn upwardly therethrough. Space 205 is provided above the top of theannular body of the liner 13 to allow the swage means 171 to passcompletely out of the top of the annular body while the reaction forcefrom the force generating means is still being applied to the settingsleeve means via thrust member 183. The setting sleeve means 173 hasconnection means 205 for connection with a supplemental element emplacedtherewith after liner 13 has been expanded into tight frictionalengagement with the casing 21 and the remainder of the setting tooldevice 11, swage means 171, and the thrust member 183 have been removedfrom the casing 21. Such an arrangement, with the connection means 205engaging second mating connection means 207 of a seal unit 209 emplacedwithin the liner 13 and the setting sleeve means 173, is illustrated inFIG. 18.

The thrust means 177 comprises an adapter means including a crossoverpin 193, skirt 195, and thrust member 183. The crossover pin 193 isretained in skirt 195 by annular ring 197 which is held in place bysuitable means such as shear pin 199. The crossover pin 193 traverseslongitudinally in slots 201 in adapter rod means 175, as indicatedhereinbefore. The skirt 295 engages, as by threaded connection orabutting engagement, the other portion of a force generating means; forexample, the bottom cylinder 43 of setting tool device 11; fortransmission of the reaction force opposing movement of the liner 13 asthe swage means 171 is pulled upwardly therethrough.

Central passageway 83 and branch passageways 85 and 86 are provided, asdescribed hereinbefore, for allowing fluid flow therethrough,facilitating rapidly changing depths in the borehole without creatingpressure surges.

In operation, the adapter rod means is connected with the bottom piston31 of the setting tooldevice 11, and the sleeve 195 abuts the bottom endof cylinder 43 of setting tool device 11. The liner 13 has its bottominterior shoulder bearing on swage means 171 and setting sleeve means173 has its shoulder portion 189 bearing on the second shoulder portion191 of thrust member 183. The assembled combination is lowered to thedesired depth in the well bore where the liner 13 is to be set.Thereafter, the setting tool device 11 is actuated, as describedhereinbefore. Setting sleeve means 173 and the liner 11 are initiallymoved downwardly as the swage means 71 is moved upwardly. The liner 13is expanded outwardly into engagement with the casing 121, however, tostop movement of the liner, as described more fully hereinbefore.Thereafter, the swage means 171 is moved upwardly completely out of thetop of the liner 13 to complete the swaging operation.

After the liner 13 has been expanded outwardly into tight frictionalengagement with the casing 21, the thrust member 183, the swage member171, and the setting tool device 11 may be moved upwardly out of thewellbore leaving the setting sleeve means 173 emplaced with the liner13. Subsequently, any suitable device may be installed in the liner. Forexample, as illustrated in FIG. 18, a seal unit 209 may be lowered intoplace, and its mating connection means 207 engaged with connection means205 such that resilient seals 209 engage the interior surface 211ofliner 13.

FIGS. 19-21 illustrate another embodiment in which the liner 13 isdisposed below both swage means 221 and setting sleeve means 223. InFIG. 19, the combination comprises, in addition to the swage means 221and setting sleeve means 223, adapter rod means 225 connecting the swagemeans with the force generating means, and tensile means 227 fortransmitting a tensile reaction force upwardly for opposing movement ofthe liner 13 as the swage means 221 is pushed downwardly therethrough.

The swage means 221 has external dimensions sized as describedhereinbefore to effect expansion of the liner 13 into tight frictionalengagement with the casing 21. Swage means 221 has a frusto-conicalsection 229. A sectioned ring means such as sectioned ring 231 isprovided for defining the cylindrical exterior having the desiredoutside diameter. The sectioned ring 231 is disposed peripherally of thefrusto-conical section 229 and is movable longitudinally thereof.Preferably, the sectioned ring 231 has a plurality of sections such assection 233 and V-shaped section 235 to facilitate withdrawal of theswage means 221 upwardly through the liner after the liner has been set.Sections 233 and 235 are coupled together to effect the desired uniformoutside diameter when positioned at the largest portion of thefrusto-conical section 229. The sections join smoothly together toeffect the desired external dimensions delineated hereinbefore and toform a continuous surface for effecting a smooth bore in the expandedliner. Sections 233 and 235 are displacable sectionally; for example,vertically; to effect a reduced outside diameter that can be readilywithdrawn upwardly through the liner after the latters expansion. Ifdesired, other forms of the sectioned ring; such as ring 237, FIG. 21;can be employed.

The adapter rod means 225 comprises a strong rodlike member with arelatively large diameter so as to be able to push the swage means 221downwardly through the liner 13. The adapter rod means 225 is connectedwith an adapter means, which includes cross link 239 and skirt 241. Thecross link 239 is retained in suitable apertures in adapter rod means225 and skirt 241 by an annular ring 243 that is held in place by shearpin 245. The cross link 239 traverses longitudinally in slots 247 in thetensile means 227. The skirt 241 engages, as by threaded connection orabutting engagement, the bottom cylinder 43 of the setting tool device11 for transmission of the requisite downward force to push the swagemeans 221 through the liner 13.

The setting sleeve means 223 has its lower end portion connected withthe liner 13 as by threaded connection 249. The setting sleeve means 223is connected with the tensile means 227. As illustrated, setting sleevemeans 223 is connected with the tensile means 227 by a detachableconnector means 251 for being detached from the tensile means 227 andleft in place with the liner 13. The detachable connector means 251comprises a plurality of paired, mating, tension-sustaining connectors;such as, apertures 253 and protrusions, or pins, 255; that are separableby lateral movement. One portion of the connector; for example, theapertures 253; are carried by the setting sleeve means 223 and the otherportion; such as, the protrusions 255; are carried by a biased portion;such as, collet fingers 257; of the tensile means 251. The biasedportion is biased for lateral movement so as to disengage the tensilemeans from the setting sleeve means when not restrained. Specifically,the collet fingers 257 are biased so as to move their ends and theprotrusions 255 inwardly to disengage the apertures 253. A restrainingmeans; such as, restraining ring 259; is disposed adjacent the colletfingers 257 for maintaining connection with the setting sleeve meansuntil the swage means has passed completely out of the annular body ofthe liner 13. The restaining ring 259 is maintained in place by shearpin 260. A shoulder portion 261 on the adapter rod 225 is moveddownwardly to shear the shear pin 260 and move the restaining ring 259from beneath the ends of the collet fingers 257 after the swage means221 has moved downwardly out of the end of the annular body of liner 13.Thus, as illustrated in FIG. 20, the liner 13 may be left emplaced intight frictional engagement with the casing 21 and the setting sleevemeans 223 connected with the top of liner 13. Space is provided belowthe bottom of the annular body of the liner 13 so as to allow the swagemeans 221 to pass completely out of the bottom of the annular body whilethe reaction force is still being applied to the setting sleeve means.

The tensile means 227, containing its collet fingers 257 and slots 247,connects the setting sleeve means 223 with an upper means 185 forconnection with a bottom piston 31 of the piston assembly of the settingtool device 11 for pulling upwardly on the setting sleeve means 223 tooppose downward movement of the liner 13 as the swage means 221 ispushed T downwardly therethrough. The tensile means 227 comprises acylindrical member which is disposed exteriorly radially of the adapterrod means 225 and is movable longitudinally with respect thereto.

in operation, combination is assembled with the tensile means 227 andthe setting sleeve means 223. connected with the bottom piston 31 of thesetting tool device 11; whereas the bottom cylinder 43 of setting tooldevice 11 is connected by the adapter means with the adapter rod means225 so as to push the swage means 221 downwardly through the liner 13.The liner 13 is connected with the setting sleeve means 223, which isconnected by the detachable connectors 251 with the tensile means 227.With the assemblage complete, the combination is lowered to the desiredtool device 11 actuated. The bottom cylinder 43 of.

setting tool device 11 will push the swage means 221 downwardly throughthe liner while the reaction force is being supplied by the pistonassembly of the setting tool device to pull upwardly via the detachableconnector means 251 on the setting sleeve means 223. After a smallamount of initial movement, the liner 13 is expanded into tightfrictional engagement with the casing 21 to constrain the liner to thedesired depth. Thereafter, the force generated by the setting tooldevice 11 pushes the swage means 221 downwardly through the liner 13 tocomplete the emplacement by expanding the liner outwardly into tightfrictional engagement with the casing. After the liner is set by theswage means 221 moving out of the lower end of the liner 13, thereleasing shoulder portion 261 moves downwardly to shear the shear pin260 and push the restraining ring 259 from under the collet fingers 257.The collet fingers 257 spring inwardly, moving the protrusions 255 outof the apertures 253 and releasing the tensile means 227 from thesetting sleeve means 233. Thereafter, the swage means, the tensilemeans, and the setting tool device 11 are removed from the well. Tofacilitate removal from the wellbore, as the swage means 221 is movedupwardly through the liner, the sectional ring 231 will be moved toeffect a reduced diameter if it encounters the set liner 13.

Except for the liner 13, the materials of construction of the respectiveelements employed in the invention are well known to those skilled inwire line operations and need not be described in detail herein.

The setting sleeve means has been illustrated and described herein asbeing primarily cylindrical in shape. It has been described in detail inspecific embodiments; such as, having expansible fingers for allowingpassage of the swage means therethrough, being connected with thesetting tool so that it is removed with the setting tool, and beingconnected with the liner for being left in the conduit with the setliner. The setting sleeve means may take any other structure, or form,of setting means as long as it provides the two functions describedhereinbefore; namely, (1) transmitting the reaction force from the forcegenerating means to the liner, and (2) allowing passage of the swagemeans completely out of the end of the liner; thereby obviating the needfor an anchor means in setting the liner in the conduit.

Also, the liner 13 has been described as having interior and exteriorsurfaces that define cylinders. The cylinders so defined need not beperfect cylinders in the mathematical sense. It is deemed within thescope of this invention if the interior and exterior surfaces definecylinders having small irregularities, or grooves, whether accidentallyor deliberately induced, as long as the irregularities are not as severeas the corrugations of the prior art; and are not sufficient to producethe nonuniform crystallographic structure or result in a tightfrictional engagement with the conduit that is unsatisfactory for theapplication for which the liner is emplaced.

It is apparent from the foregoing drawings and description that theinvention accomplishes its objects of providing an improved method ofsetting a liner in a conduit in a wellbore penetrating subterraneanformations, and providing combinations of apparatus that:

I. employ a cylindrical liner,

2. do not depend upon a separate supplemental support, or anchor, tohold the liner in place for setting in the conduit,

3. do not depend on an outside coating of resilient material forsealing,

4. do not require additional pieces to be retained in the well to retainthe liner in place in the conduit,

5. are not limited to thin walled sections,

6. effect a more nearly uniform crystallo-graphic structure at themetallurgical crystalline structure level without regions of low yieldstrength caused by large flexure such as corrugations,

7. have a large smooth internal bore that forms a uniform internaldiameter for seating additional elements thereon,

8. may be emplaced at any point without being restricted to joints,

9. are operable by means of a wire line without requiring an additionalstring of pipe,

10. do not require a plurality of trips into the well to effect passageof the swage means completely through the liner,

1 1. do not destroy equipment by an uncontained explosion in the well;and

12. in a particular embodiment, leave a liner that is physically,chemically, and electrochemically, compatible with the conduit in thewell and the job the liner is required to do.

Although the invention has been described with a certain degree ofparticularity, it is understood that the present disclosure has beenmade only by way of example and that numerous changes in the details ofconstruction and the combination and arrangement of parts may beresorted to without departing from the spirit and the scope of theinvention.

What is claimed is:

l. A method of emplacing a liner in a conduit in a well penetratingsubterranean formations comprising:

a. positioning via a wire line at a given depth in said conduit anannular liner having substantially cylindrical interior and exteriorsurfaces that are at least partially coextensive, having an outsidediameter less than the internal diameter of said conduit, havingsufficient malleability for and being adapted for being expanded toconformingly engage said conduit, having a thickness sufficient toeffect a wall after expansion capable of withstanding the pressurewithin or outside said conduit, and heaving a modulus of elasticity incompression sufficient to retain tight frictional engagement with saidconduit after expansion thereagainst; said liner being disposed adjacenta swage means for expanding said liner outwardly into said tightfrictional engagement with said conduit and adjacent a setting sleevemeans for holding said liner at the desired setting depth against theforce of said swage means as said swage means is forced through saidliner; said swage means engaging a force generating means suspended onsaid wire line for subjecting said swage means to a force acting toforce said swage through said liner; and said setting sleeve meansengaging said force generating means for subjecting said setting sleevemeans to a reaction force opposing movement of said liner as said swagemeans is forced therethrough;

b. actuating said force generating means and applying said force to saidswage means and said reaction force to said setting sleeve means,thereby forcing said swage means completely through and out of saidliner while said reaction force is still acting on said liner, andexpanding said liner outwardly into tight frictional engagement withsaid conduit; and thereafter;

0. removing said force generating means and said swage means from saidwell, leaving said liner expanded into said tight frictional engagementwith said conduit and having an unusually large aperture penetratinglongitudinally therethrough.

2. The method of claim 1 wherein said liner is disposed below both saidswage means and said setting sleeve means and is connected with saidsetting sleeve means; said swage means engaging said force generatingmeans for subjecting sad swage means to a force acting downwardly andsaid setting sleeve means being connected with said force generatingmeans for subjecting said setting sleeve means to a reaction forceacting upwardly; and wherein said force generating means is actuated topush said swage means downwardly completely out of the bottom of saidliner, which is held by said setting sleeve means, while said reactionforce is still acting upwardly on said liner.

3. The method of claim 2 wherein said setting sleeve means is connectedwith the top of said liner and is detachably connected with said forcegenerating means; and wherein said setting sleeve means is detachedduring the operation of setting said liner and is left in said conduitwith said liner expanded into tight frictional engagement with saidconduit.

4. The method of claim 3 wherein a reduced outside diameter of saidswage means is effected to facilitate removal of said swage meansupwardly through the expanded liner.

5. The method of claim 1 wherein said liner is disposed above both saidswage means and said setting sleeve means and is connected with saidsetting sleeve means, said swage means being connected with said forcegenerating means for subjecting said swage means to a force actingupwardly and said setting sleeve means engaging said forcegenerating-means for subjecting said setting sleeve means to a reactionforce acting downwardly; and wherein said force generating means isactuated to pull said swage means completely through and out of the topof said liner, which is held by said setting sleeve means, while saidreaction force is still acting downwardly on said liner.

6. The method of claim 5 wherein said setting sleeve means is connectedwith the bottom of said liner and has a portion that abuts a portion ofa downwardly extending thrust member that is subjected to said reactionforce from said force generating means, and said setting sleeve means isleft in said conduit with said liner expanded into tight frictionalengagement with said conduit.

'7. The method of claim 6 wherein said setting sleeve means hasconnection means for connecting with a supplemental element emplacedtherewithin.

8. The method of claim 7 wherein a seal unit is emplaced within saidliner and said setting sleeve means, and has seal means engaging alongitudinally extending surface defining an internal bore in saidliner, said longitudinally extending surface being effected by saidswage means in expanding said liner outwardly into said tight frictionalengagement with said conduit; said seal unit having a mating secondconnection means engaging said connection means.

9. The method of claim 1 wherein said liner is disposed above said swagemeans and below said setting sleeve means, said swage means beingconnected with said force generating means for subjecting said swagemeans to a force acting upwardly and said setting sleeve means engagingsaid force generating means for subjecting said setting sleeve means toa reaction force acting downwardly; and wherein said force generatingmeans is actuated to pull said swage means completely through and out ofthe top of said liner, which bears against said setting sleeve means,and into a portion of said setting sleeve means while said reactionforce is still acting downwardly on said liner.

10. The method of claim 9 wherein said swage means is pulled upwardlythrough said liner in a single stroke.

11. The method of claim 9 wherein said force generating means comprisesa setting tool of a type wherein a piston assembly and a cylinderassembly are powered for relative movement by an ignitable charge.

12. The method of claim 11 wherein said setting sleeve means isconnected with said setting tool, has flexible expander means and anexpander support ring disposed concentrically within said expander meansfor support and wherein said swage means moves said expander supportring from within said expander means upon its passage therepast, saidexpander means expanding outwardly to allow passage of said swage meansand springing inwardly to a position of normal repose thereafter,whereby a large upwardly acting force may be applied to said swage meanswithout distorting said setting sleeve means, and said liner can beemplaced in said conduit with a single actuation of said forcegenerating means and a single passage upwardly of said swage means.

13. The method of claim 9 wherein said liner positioned at said givendepth in said conduit is connected with a second said liner via aconnector means, which includes an elongate sleeve portion; said swagemeans is connected with a second swage means that has a slightly smallerdiameter than said swage means and is arranged below said second liner;said swage means is pulled through said liner and said second swagemeans is pulled through said second liner to expand both linersoutwardly into frictional and sealing engagement with said conduit; andboth said swage means are removed in accordance with step (c) of claim1.

14. The method of claim 13 wherein said swage means and said secondswage means are drawn, respectively, through said liner and said secondliner singly, whereby said force generating means does not have togenerate a force great enough to pull both swaging means through bothliners simultaneously.

15. A combination of liner and apparatus for setting the liner inconduit in a well penetrating subterranean formations comprising:

a. a liner including an annular body portion having substantiallycylindrical interior and exterior surfaces that are at least partiallycoextensive, having an outside diameter less than the diameter of saidconduit, having sufficient malleability for and adapted for beingexpanded to conformingly engage said conduit, having a wall thicknesssufficient to effect a wall after expansion capable of withstanding thepressure within or outside said conduit, and having a modulus ofelasticity in compression sufficient to retain tight frictionalengagewith said ment conduit after expansion thereagainst; b. swagemeans adjacent said liner for moving through and expanding said lineroutwardly into tight frictional engagement with said conduit, theexternal dimensions of said swage means having been pre-selected inaccordance with the internal dimensions of said conduit and the diameterand wall thickness of said liner to effect said tight frictionalengagement with said conduit after expansron;

c. an adapter rod means for connecting said swage means with a forcegenerating means; said adapter rod means being connected at one endportion with said swage means and having, at the other end portion,means for engagement with a force generating means for subjecting saidswage means to a force acting to move said swage means completelythrough said liner and expand said liner into said tight frictionalengagement with said conduit; and

(1. setting sleeve means disposed radially of the central axis of saidadapter rod means and adjacent said liner and having means forengagement with said force generating means for opposing movement ofsaid liner by transmission of a reaction force that acts oppositely tosaid force from said force generating means; said setting sleeve meansbeing constructed and disposed so as to allow movement of said swagemeans completely out of said annular body of said liner while saidreaction force is still being applied to said liner.

16. The combination of claim 15 wherein said liner has a top portionintegrally connected with said body portion and said top portion has aninner inverted frusto-conical section to form a stabbing section tofacilitate entry of other elements into said liner once emplaced in saidwell.

17. The combination of claim 16 wherein said top portion has a pluralityof notches in its top edge.

18. The combination of claim 15 wherein said swage means is disposedbelow said liner; said adapter rod means passes through said liner forpulling said swage means upwardly through and completely out of the topof said liner; said setting sleeve means is disposed below said linerwith its upper end portion connected with said liner and has a portionthat abuts a downwardly extending thrust member, said thrust memberhaving means for engaging said force generating means and adapted fortransmitting a downwardly acting reaction force for opposing movement ofsaid liner when said swage means is pulled upwardly therethrough; andspace is provided above the top of said annular body of said liner toallow said swage means to pass completely out of the top of said annularbody while said reaction force is still being applied to said settingsleeve means.

19. The combination of claim 31 wherein said setting sleeve means hasconnection means for connection with a supplemental element emplacedtherewithin; is sealingly connected with said liner, and removably abutssaid thrust member such that said thrust member may be removed with saidswage means and said setting sleeve means left in said conduit with saidliner expanded into tight frictional engagement with said conduit.

20. The combination of claim wherein said swage means is disposed abovesaid liner; said adapter rod means is adapted for transmitting saidforce downwardly for pushing said swage means downwardly through saidliner; said setting sleeve means is disposed above said liner with itslower end portion connected with said liner and is connected with atensile means for transmitting a tensile force upwardly, said tensilemeans having means for engaging said force generating means and adaptedfor transmitting said reaction force upwardly for opposing movement ofsaid liner when said swage means is pushed downwardly therethrough; andspace is provided below the bottom of said annular body of said liner toallow said swage means to pass completely out of the bottom of saidannular body while said reaction force is till being applied to saidsetting sleeve means.

21. The combination of claim wherein said swage means has afrusto-conical section and a sectioned ring means for effecting saidexternal dimensions of said swage means; said sectioned ring means beingdisposed peripherally of said frusto-conical section and freely movablelongitudinally thereof, said sectioned ring means having a plurality ofsections coupled together so as to effect an outside diameter whenpositioned at the largest portion of said frusto-conical section thateffects said external dimensions of said swage means and is continuousfor effecting a smooth bore in said liner; said sections beingdisplacable sectionally vertically so as to effect a reduced outsidediameter that can be readily withdrawn upwardly through said liner afteremplacement.

22. The combination of claim 20 wherein said setting sleeve means isconnected with the top of said liner and is connected with said tensilemeans via detachable connector means for being detached from saidtensile means and left in place with said liner in said conduit.

23. The combination of claim 22 wherein said detachable connector meanscomprises a plurality of paired, mating, tension-sustaining connectorsthat are separable by lateral movement, one portion being carried bysaid setting sleeve means and one portion being carried by a biasedportion of said tensile means that is biased for lateral movement so asto disengage from said setting sleeve means when not restrained, and arestraining means is disposed adjacent said biased portion formaintaining connection with said setting sleeve means until said swagemeans has passed completely out of said annular body of said liner.

24. The combination of claim 23 wherein said restraining means comprisesa restraining ring and a shearable means for maintaining saidrestraining ring adjacent said biased portion; and said adapter rodmeans has a shoulder portion for shearing said sheara ble means andmoving said restraining ring downwardly to release said biased portionafter said swage means has passed downwardly through said liner andexpanded it into tight frictional engagement with said conduit.

25. The combination of claim 23 wherein said paired connectors compriserespective mating apertures and protrusions.

26. The combination of claim 25 wherein said apertures are disposed insaid setting sleeve means and said protrusions are carried by saidbiased portion, and said biased portion comprises inwardly biased colletfingers.

27. The combination of claim 15 wherein said swage means is disposedbelow said liner; said adapter rod means'passes through said liner forpulling said swage means upwardly through and completely out of the topof said liner; said setting sleeve means is disposed above said linerwith its lower end portion engaging the top of said liner and has meansat its upper end portion for engagement with the force generating meansand adapted for transmitting a downwardly acting said reaction force foropposing upward movement of said liner when said swage means is pulledupwardly therethrough; and said setting sleeve means has means allowingmovement of said swage means completely out of the top of said liner andwithin a portion of said setting sleeve means while said reaction forceis still being applied to said setting sleeve means.

28. The combination of claim 27 wherein one of said adapter rod and saidsetting sleeve means are operatively connected with one of a pistonassembly of a setting tool and a cylinder assembly of said setting toolfor transmission respectively of said force acting upwardly and saiddownward acting reaction force; and said setting tool comprises a fluidactuated means means comprising a head assembly including igniter means,said cylinder assembly and said piston assembly within said cylinderassembly, with said piston assembly being slideable relative to saidcylinder assembly; means including a combustion chamber adapted forreceiving a combustible material power charge and disposed within saidcylinder assembly for imparting relative motion to said cylinderassembly relative to said piston assembly to move said swage meansupwardly through said liner, movement of which is 0pposed by saidsetting sleeve means.

29. The combination of claim 27 wherein said setting sleeve meansexpandably engages the top of said liner via flexible spring fingers forretaining said liner in place during setting, said spring fingers beingadapted to flex outwardly to allow passage of said swage meanstherethrough and spring back into position after said swage means haspassed therethrough.

30. The combination of claim 2Q wherein an expander support ring isemployed in said setting sleeve and is held in place adjacent said linerand within said flexible spring fingers with a shearable means forsupporting said fingers during the interaction of the large force andreactive force pulling said swage means through said liner, saidexpander support ring having a shoulder for conformingly engaging aportion of said swage means after said swage means has passed throughsaid liner and for moving said expander support ring upwardly as saidswage means passes upwardly out of said liner.

31. The combination of claim 27 wherein the bottom of said body portionof said liner is sealingly connected with one end of a connector meansand said connector means is sealingly connected at its other end with aterminal element.

32. The combination of claim 31 wherein said terminal element is atleast a section of a production liner whereby said section of saidproduction liner and any extensions thereof desired can be emplaced at agiven location in said conduit by expansion of said body por tion intofrictional and sealing engagement with said conduit, and said productionliner will resist being displaced upwardly by pressure or downwardly byits own weight.

33. The combination of claim 31 wherein said terminal element is a bullplug seal means and wherein said bull plug seal means can be emplaced ata given location in said conduit by expansion of said annular bodyportion into frictional and sealing engagement with said conduit andsaid bull plug seal means will resist being displaced upwardly ordownwardly by force of a pressure acting thereon.

34. The combination of claim 31- wherein said terminal element is asecond liner smaller than the diameter of said conduit, said secondliner is sealingly connected at one end to said connector means via anexpansible portion, and said connector means includes an elongate sleeveportion, to form a straddle patch for emplacing in said conduit forblocking a communicating passageway between the interior of said conduitand the exterior of said conduit; and wherein said swage means isconnected with a second swage means below said second liner, said secondswage means having a diameter slightly less than said swage means, saidsecond swage means and said second liner cooperating to effect sealingengagement of said second liner with said conduit when said second swagemeans is drawn upwardly through said second liner; whereby said secondswage means can also pass through said liner after said swage means hasexpanded said liner into contact with said conduit.

35. The combination of claim 34 wherein said second swage means isimmediately below and contiguous. with said second liner and said swagemeans is spaced a distance below said liner sufficient to enable saidsecond swage means to traverse through said second liner before saidswage means starts its traverse of said liner.

36. The combination of claim 31 wherein said terminal element comprisesa seal sub having a longitudinally extending internal sealing surfacedefining a bore for receiving in sealing relationship a large borepacker including single bore packers such as sea] nipples; whereby saidseal sub can be emplaced at a given location in said conduit byexpansion of said annular body portion into frictional and sealingengagement with said conduit and said seal sub will resist beingdisplaced upwardly or downwardly by a weight and the force of a pressureacting thereon.

37. The combination of claim 36 wherein there is included a large borepacker that conformingly and sealingly fits within said bore of saidseal sub and has a portion that seals contiguous said sealing surface.

38. The combination of claim 37 wherein said large bore packer comprisesa body having a longitudinally extending aperture penetratingtherethrough.

39. The combination of claim 38 wherein said large bore packer body hasa plurality of apertures extending longitudinally therethrough.

1. A method of emplacing a liner in a conduit in a well penetratingsubterranean formations comprising: a. positioning via a wire line at agiven depth in said conduit an annular liner having substantiallycylindrical interior and exterior surfaces that are at least partiallycoextensive, having an outside diameter less than the internal diameterof said conduit, having sufficient malleability for and being adaptedfor being expanded to conformingly engage said conduit, having athickness sufficient to effect a wall after expansion capable ofwithstanding the pressure within or outside said conduit, and heaving amodulus of elasticity in compression sufficient to retain tightfrictional engagement with said conduit after expansion thereagainst;said liner being disposed adjacent a swage means for expanding saidliner outwardly into said tight frictional engagement with said conduitand adjacent a setting sleeve means for holding said liner at thedesired setting depth against the force of said swage means as saidswage means is forced through said liner; said swage means engaging aforce generating means suspended on said wire line for subjecting saidswage means to a force acting to force said swage through said liner;and said setting sleeve means engaging said force generating means forsubjecting said setting sleeve means to a reaction force opposingmovement of said liner as said swage means is forced therethrough; b.actuating said force generating means and applying said force to saidswage means and said reaction force to said setting sleeve means,thereby forcing said swage means completely through and out of saidliner while said reaction force is still acting on said liner, andexpanding said liner outwardly into tight frictional engagement withsaid conduit; and thereafter; c. removing said force generating meansand said swage means from said well, leaving said liner expanded intosaid tight frictional engagement with said conduit and having anunusually large aperture penetrating longitudinally therethrough.
 2. Themethod of claim 1 wherein said liner is disposed below both said swagemeans and said setting sleeve means and is connected with said settingsleeve means; said swage means engaging said force generating means forsubjecting sad swage means to a force acting downwardly and said settingsleeve means being connected with said force generating means forsubjecting said setting sleeve means to a reaction force actingupwardly; and wherein said force generating means is actuated to pushsaid swage means downwardly completely out of the bottom of said liner,which is held by said setting sleeve means, while said reaction force isstill acting upwardly on said liner.
 3. The method of claim 2 whereinsaid setting sleeve means is connected with the top of said liner and isdetachably connected with said force generating means; and wherein saidsetting sleeve means is detached during the operation of setting saidliner and is left in said conduit with said liner expanded into tightfrictional engagement with said conduit.
 4. The method of claim 3wherein a reduced outside diameter of saId swage means is effected tofacilitate removal of said swage means upwardly through the expandedliner.
 5. The method of claim 1 wherein said liner is disposed aboveboth said swage means and said setting sleeve means and is connectedwith said setting sleeve means, said swage means being connected withsaid force generating means for subjecting said swage means to a forceacting upwardly and said setting sleeve means engaging said forcegenerating means for subjecting said setting sleeve means to a reactionforce acting downwardly; and wherein said force generating means isactuated to pull said swage means completely through and out of the topof said liner, which is held by said setting sleeve means, while saidreaction force is still acting downwardly on said liner.
 6. The methodof claim 5 wherein said setting sleeve means is connected with thebottom of said liner and has a portion that abuts a portion of adownwardly extending thrust member that is subjected to said reactionforce from said force generating means, and said setting sleeve means isleft in said conduit with said liner expanded into tight frictionalengagement with said conduit.
 7. The method of claim 6 wherein saidsetting sleeve means has connection means for connecting with asupplemental element emplaced therewithin.
 8. The method of claim 7wherein a seal unit is emplaced within said liner and said settingsleeve means, and has seal means engaging a longitudinally extendingsurface defining an internal bore in said liner, said longitudinallyextending surface being effected by said swage means in expanding saidliner outwardly into said tight frictional engagement with said conduit;said seal unit having a mating second connection means engaging saidconnection means.
 9. The method of claim 1 wherein said liner isdisposed above said swage means and below said setting sleeve means,said swage means being connected with said force generating means forsubjecting said swage means to a force acting upwardly and said settingsleeve means engaging said force generating means for subjecting saidsetting sleeve means to a reaction force acting downwardly; and whereinsaid force generating means is actuated to pull said swage meanscompletely through and out of the top of said liner, which bears againstsaid setting sleeve means, and into a portion of said setting sleevemeans while said reaction force is still acting downwardly on saidliner.
 10. The method of claim 9 wherein said swage means is pulledupwardly through said liner in a single stroke.
 11. The method of claim9 wherein said force generating means comprises a setting tool of a typewherein a piston assembly and a cylinder assembly are powered forrelative movement by an ignitable charge.
 12. The method of claim 11wherein said setting sleeve means is connected with said setting tool,has flexible expander means and an expander support ring disposedconcentrically within said expander means for support and wherein saidswage means moves said expander support ring from within said expandermeans upon its passage therepast, said expander means expandingoutwardly to allow passage of said swage means and springing inwardly toa position of normal repose thereafter, whereby a large upwardly actingforce may be applied to said swage means without distorting said settingsleeve means, and said liner can be emplaced in said conduit with asingle actuation of said force generating means and a single passageupwardly of said swage means.
 13. The method of claim 9 wherein saidliner positioned at said given depth in said conduit is connected with asecond said liner via a connector means, which includes an elongatesleeve portion; said swage means is connected with a second swage meansthat has a slightly smaller diameter than said swage means and isarranged below said second liner; said swage means is pulled throughsaid liner and said second swage means is pulled through said secondliner to expand both liners outwardly iNto frictional and sealingengagement with said conduit; and both said swage means are removed inaccordance with step (c) of claim
 1. 14. The method of claim 13 whereinsaid swage means and said second swage means are drawn, respectively,through said liner and said second liner singly, whereby said forcegenerating means does not have to generate a force great enough to pullboth swaging means through both liners simultaneously.
 15. A combinationof liner and apparatus for setting the liner in conduit in a wellpenetrating subterranean formations comprising: a. a liner including anannular body portion having substantially cylindrical interior andexterior surfaces that are at least partially coextensive, having anoutside diameter less than the diameter of said conduit, havingsufficient malleability for and adapted for being expanded toconformingly engage said conduit, having a wall thickness sufficient toeffect a wall after expansion capable of withstanding the pressurewithin or outside said conduit, and having a modulus of elasticity incompression sufficient to retain tight frictional engagement with saidconduit after expansion thereagainst; b. swage means adjacent said linerfor moving through and expanding said liner outwardly into tightfrictional engagement with said conduit, the external dimensions of saidswage means having been pre-selected in accordance with the internaldimensions of said conduit and the diameter and wall thickness of saidliner to effect said tight frictional engagement with said conduit afterexpansion; c. an adapter rod means for connecting said swage means witha force generating means; said adapter rod means being connected at oneend portion with said swage means and having, at the other end portion,means for engagement with a force generating means for subjecting saidswage means to a force acting to move said swage means completelythrough said liner and expand said liner into said tight frictionalengagement with said conduit; and d. setting sleeve means disposedradially of the central axis of said adapter rod means and adjacent saidliner and having means for engagement with said force generating meansfor opposing movement of said liner by transmission of a reaction forcethat acts oppositely to said force from said force generating means;said setting sleeve means being constructed and disposed so as to allowmovement of said swage means completely out of said annular body of saidliner while said reaction force is still being applied to said liner.16. The combination of claim 15 wherein said liner has a top portionintegrally connected with said body portion and said top portion has aninner inverted frusto-conical section to form a stabbing section tofacilitate entry of other elements into said liner once emplaced in saidwell.
 17. The combination of claim 16 wherein said top portion has aplurality of notches in its top edge.
 18. The combination of claim 15wherein said swage means is disposed below said liner; said adapter rodmeans passes through said liner for pulling said swage means upwardlythrough and completely out of the top of said liner; said setting sleevemeans is disposed below said liner with its upper end portion connectedwith said liner and has a portion that abuts a downwardly extendingthrust member, said thrust member having means for engaging said forcegenerating means and adapted for transmitting a downwardly actingreaction force for opposing movement of said liner when said swage meansis pulled upwardly therethrough; and space is provided above the top ofsaid annular body of said liner to allow said swage means to passcompletely out of the top of said annular body while said reaction forceis still being applied to said setting sleeve means.
 19. The combinationof claim 31 wherein said setting sleeve means has connection means forconnection with a supplemental element emplaced therewithin; issealingly connected with said liner, and removably abuts said thrustmember such that said thrust member may be removed with said swage meansand said setting sleeve means left in said conduit with said linerexpanded into tight frictional engagement with said conduit.
 20. Thecombination of claim 15 wherein said swage means is disposed above saidliner; said adapter rod means is adapted for transmitting said forcedownwardly for pushing said swage means downwardly through said liner;said setting sleeve means is disposed above said liner with its lowerend portion connected with said liner and is connected with a tensilemeans for transmitting a tensile force upwardly, said tensile meanshaving means for engaging said force generating means and adapted fortransmitting said reaction force upwardly for opposing movement of saidliner when said swage means is pushed downwardly therethrough; and spaceis provided below the bottom of said annular body of said liner to allowsaid swage means to pass completely out of the bottom of said annularbody while said reaction force is till being applied to said settingsleeve means.
 21. The combination of claim 20 wherein said swage meanshas a frusto-conical section and a sectioned ring means for effectingsaid external dimensions of said swage means; said sectioned ring meansbeing disposed peripherally of said frusto-conical section and freelymovable longitudinally thereof, said sectioned ring means having aplurality of sections coupled together so as to effect an outsidediameter when positioned at the largest portion of said frusto-conicalsection that effects said external dimensions of said swage means and iscontinuous for effecting a smooth bore in said liner; said sectionsbeing displacable sectionally vertically so as to effect a reducedoutside diameter that can be readily withdrawn upwardly through saidliner after emplacement.
 22. The combination of claim 20 wherein saidsetting sleeve means is connected with the top of said liner and isconnected with said tensile means via detachable connector means forbeing detached from said tensile means and left in place with said linerin said conduit.
 23. The combination of claim 22 wherein said detachableconnector means comprises a plurality of paired, mating,tension-sustaining connectors that are separable by lateral movement,one portion being carried by said setting sleeve means and one portionbeing carried by a biased portion of said tensile means that is biasedfor lateral movement so as to disengage from said setting sleeve meanswhen not restrained, and a restraining means is disposed adjacent saidbiased portion for maintaining connection with said setting sleeve meansuntil said swage means has passed completely out of said annular body ofsaid liner.
 24. The combination of claim 23 wherein said restrainingmeans comprises a restraining ring and a shearable means for maintainingsaid restraining ring adjacent said biased portion; and said adapter rodmeans has a shoulder portion for shearing said shearable means andmoving said restraining ring downwardly to release said biased portionafter said swage means has passed downwardly through said liner andexpanded it into tight frictional engagement with said conduit.
 25. Thecombination of claim 23 wherein said paired connectors compriserespective mating apertures and protrusions.
 26. The combination ofclaim 25 wherein said apertures are disposed in said setting sleevemeans and said protrusions are carried by said biased portion, and saidbiased portion comprises inwardly biased collet fingers.
 27. Thecombination of claim 15 wherein said swage means is disposed below saidliner; said adapter rod means passes through said liner for pulling saidswage means upwardly through and completely out of the top of saidliner; said setting sleeve means is disposed above said liner with itslower end portion engaging the top of said liner and has means at itsupper end portion for engagement with the force generating means andadapted for transmitting a downwardLy acting said reaction force foropposing upward movement of said liner when said swage means is pulledupwardly therethrough; and said setting sleeve means has means allowingmovement of said swage means completely out of the top of said liner andwithin a portion of said setting sleeve means while said reaction forceis still being applied to said setting sleeve means.
 28. The combinationof claim 27 wherein one of said adapter rod and said setting sleevemeans are operatively connected with one of a piston assembly of asetting tool and a cylinder assembly of said setting tool fortransmission respectively of said force acting upwardly and saiddownward acting reaction force; and said setting tool comprises a fluidactuated means means comprising a head assembly including igniter means,said cylinder assembly and said piston assembly within said cylinderassembly, with said piston assembly being slideable relative to saidcylinder assembly; means including a combustion chamber adapted forreceiving a combustible material power charge and disposed within saidcylinder assembly for imparting relative motion to said cylinderassembly relative to said piston assembly to move said swage meansupwardly through said liner, movement of which is opposed by saidsetting sleeve means.
 29. The combination of claim 27 wherein saidsetting sleeve means expandably engages the top of said liner viaflexible spring fingers for retaining said liner in place duringsetting, said spring fingers being adapted to flex outwardly to allowpassage of said swage means therethrough and spring back into positionafter said swage means has passed therethrough.
 30. The combination ofclaim 29 wherein an expander support ring is employed in said settingsleeve and is held in place adjacent said liner and within said flexiblespring fingers with a shearable means for supporting said fingers duringthe interaction of the large force and reactive force pulling said swagemeans through said liner, said expander support ring having a shoulderfor conformingly engaging a portion of said swage means after said swagemeans has passed through said liner and for moving said expander supportring upwardly as said swage means passes upwardly out of said liner. 31.The combination of claim 27 wherein the bottom of said body portion ofsaid liner is sealingly connected with one end of a connector means andsaid connector means is sealingly connected at its other end with aterminal element.
 32. The combination of claim 31 wherein said terminalelement is at least a section of a production liner whereby said sectionof said production liner and any extensions thereof desired can beemplaced at a given location in said conduit by expansion of said bodyportion into frictional and sealing engagement with said conduit, andsaid production liner will resist being displaced upwardly by pressureor downwardly by its own weight.
 33. The combination of claim 31 whereinsaid terminal element is a bull plug seal means and wherein said bullplug seal means can be emplaced at a given location in said conduit byexpansion of said annular body portion into frictional and sealingengagement with said conduit and said bull plug seal means will resistbeing displaced upwardly or downwardly by force of a pressure actingthereon.
 34. The combination of claim 31 wherein said terminal elementis a second liner smaller than the diameter of said conduit, said secondliner is sealingly connected at one end to said connector means via anexpansible portion, and said connector means includes an elongate sleeveportion, to form a straddle patch for emplacing in said conduit forblocking a communicating passageway between the interior of said conduitand the exterior of said conduit; and wherein said swage means isconnected with a second swage means below said second liner, said secondswage means having a diameter slightly less than said swage means, saidsecond swage means and said second liner cooperating to effect seaLingengagement of said second liner with said conduit when said second swagemeans is drawn upwardly through said second liner; whereby said secondswage means can also pass through said liner after said swage means hasexpanded said liner into contact with said conduit.
 35. The combinationof claim 34 wherein said second swage means is immediately below andcontiguous with said second liner and said swage means is spaced adistance below said liner sufficient to enable said second swage meansto traverse through said second liner before said swage means starts itstraverse of said liner.
 36. The combination of claim 31 wherein saidterminal element comprises a seal sub having a longitudinally extendinginternal sealing surface defining a bore for receiving in sealingrelationship a large bore packer including single bore packers such asseal nipples; whereby said seal sub can be emplaced at a given locationin said conduit by expansion of said annular body portion intofrictional and sealing engagement with said conduit and said seal subwill resist being displaced upwardly or downwardly by a weight and theforce of a pressure acting thereon.
 37. The combination of claim 36wherein there is included a large bore packer that conformingly andsealingly fits within said bore of said seal sub and has a portion thatseals contiguous said sealing surface.
 38. The combination of claim 37wherein said large bore packer comprises a body having a longitudinallyextending aperture penetrating therethrough.
 39. The combination ofclaim 38 wherein said large bore packer body has a plurality ofapertures extending longitudinally therethrough.